Greenland is the largest island and least densely populated country on Earth. Its 57,000 inhabitants are spread over a vast area the size of Western Europe, with most living in small communities along the fjords of the west coast. Most of these communities are accessible only by boat or airplane during the summer and by dog sled in winter. But as HARMEET BAWA writes, due to the self-contained nature of Greenland communities, each town generates its own energy and distributes it via a micro-power grid and local district heating network. This article originally appeared in The Circle 03.15.
HISTORICALLY, this energy has been generated in Greenland by diesel-driven power plants, which require costly imports of fossil fuel and are the biggest single contributor to the island’s greenhouse gas emissions.
In recent years, however, Greenland has been replacing its diesel power plants with hydropower plants – using its vast resources of glacial meltwater to generate lower cost hydropower and reduce the country’s fuel imports and greenhouse gas emissions.
The latest of these renewable energy projects is a 22.5 megawatt (MW) hydropower plant for the town of Ilulissat on the west coast, the third largest community in Greenland with a population of 4,541 as of 2013. The plant replaces an existing diesel-driven power plant and will provide electricity for the town and the local district heating network.
Asea Brown Boveri (ABB), a global leader in power and automation technologies, was selected to supply a complete electrical and control solution for the hydropower plant by the Icelandbased engineering, procurement and construction contractor, Ístak.
Operational reliability is critical for the plant owner, Nukissiorfiit, the government-owned energy provider. The plant is unmanned and located in an isolated fjord 45 km from Ilulissat. If a fault were to occur during harsh winter storms, access would not be possible for days or weeks and the old diesel-driven power plant would have to be restarted at great inconvenience and extra cost.
This is the third complete power and automation solution that ABB has supplied for Greenland’s ongoing push to renewable energy. In 2010, ABB supplied a similar solution for a new 15 MW hydropower plant that supplies Sisimiut, the island’s second largest town, with clean electric power. Prior to that in 2007, ABB completed the delivery and commissioning of the communication and control system for the 9 MW Qorlortorsuaq hydropower plant.
As a result of these and other hydropower projects, almost 70 percent of Greenland’s electricity is now generated by emission-free hydropower.
HARMEET BAWA is head of communications for ABB’s Power Products and Power Systems.

The imminent threat of climate change has governments around the world attempting to set targets for increased energy efficiency, energy saving and the transition from fossil fuels to fuels with a low carbon footprint. GUÐNI JÓHANNESSON notes that Iceland’s provision of one hundred per cent of space heating and electricity through hydropower and geothermal energy was not an accident of nature, but a national goal. This article originally appeared in The Circle 03.15.
IT IS TRUE that Iceland has abundant resources in hydropower and geothermal energy but so have many other countries. The difference is that development of Iceland’s renewable resources occurred through publicly financed initial research and development. This was followed by the introduction of renewables on a large scale supported by a strong national policy to create necessary market conditions and a viable business environment. It was recognized that factors such as energy security, lower pollution and CO2 emissions plus long term impact on the balance of trade must be given a price tag for the transition to take place.
In Iceland, extensive research was carried out with government support in order to identify and develop new geothermal sources. The first projects were usually in areas where geothermal sources were obvious and in the vicinity of populated areas. A brilliant move by the government in the 1930s also saw the building of new centres for education and regional services close to known geothermal sources. A considerable development of greenhouses owned by private entrepreneurs was also fostered where geothermal water was available.
In the 1960s about forty per cent of space heating was geothermal energy, with the remainder provided mainly by oil. A search for sourceswhere little or no surface indications were available had to take place. Since district heating systems in smaller communities and less densely populated areas would be more difficult to finance with sales revenues, state aid at that time included a risk mitigation fund sharing the risk for drilling and direct support for the build up of district heating in remote areas.
In places where geothermal energy was yet to be found, district heating systems running on low priority electricity in combination with oil were built. However, many houses in the sixties were built with direct electrical heating which made it less lucrative for these homeowners to convert to district heating than for those who had an oil burner with a hydronic heating system which uses water or another liquid heat transfer medium. The government also guaranteed loans in US dollars which enhanced the investments but put a heavy strain on the economy of the district heating companies when the Icelandic currency was devalued.
The district heating companies are in most cases owned by municipalities and run on a cost plus basis as a service to the inhabitants. This means that as the financing has been paid off over time and since operational costs are low, the cost for heating can be down to 1-2 US cents per kWh. This makes a huge difference in the cost of living in a country with heating demands over the entire year.
Generating electricity with geothermal energy has increased significantly in recent years. As a result of a rapid expansion in Iceland’s energy intensive industry, the demand for electricity has increased considerably. The figure shows the development from 1970-2013. The installed generation capacity of geothermal power plants totaled 665 MWe (megawatt electric, the electric output of a power plant in megawatts) in 2013 and the production was 4,600 GWh, or 24.5% of the country’s total electricity production. The construction and operation of the power plant Krafla was challenging due to difficult chemistry and volcanic activity in the region. However, once technical problems were overcome and operation secured, geothermal resources developed rapidly in the late 1990s.
The Iceland Deep Drilling Project (IDDP) is a long term study of hightemperature hydrothermal systems in Iceland. It is a collaborative effort by a consortium of Icelandic power companies and the Icelandic government to determine whether geothermal fluids would improve the economics of power production from geothermal fields. Over the next several years the IDDP expects to drill and test a series of boreholes beneath three currently exploited geothermal fields in Iceland. This will require drilling to a depth of about 5 km in order to reach hydrothermal fluids at temperatures ranging from 450°C to ~600°C.
Further outreach includes the Geothermal Training Programme of the United Nations University (UNU-GTP), established in Iceland in 1978 when Orkustofnun – the National Energy Authority of Iceland – became an Associated Institution of the UNU. Since 1979, a group of professional scientists and engineers from the developing and transitional countries have come to Iceland annually to spend six months on highly specialized studies, research, and on-the-job training in geothermal science and engineering.
DR. GUÐNI A. JÓHANNESSON is the Director General of Iceland’s National Energy Authority.

 

Colville Lake is a small, remote community in the Northwest Territories (NWT) of Canada, north of the Arctic Circle – not the first place one might think of for solar power. As Klaus Dohring writes, the climate in Colville Lake is typical of the far north with challenging winters, but sun-rich summers. This article originally appeared in The Circle 03.15.
The only overland connection to Colville Lake – a community of about 160, mostly Dene First Nation residents – is the seasonal winter ice road, open about six weeks each year. We travelled to Colville Lake in June 2015 to install what we believe is the most advanced renewable energy project in the north to date. At that time of year, it doesn’t get dark at all. The sun intensity all summer is remarkable, and the sun hours are plentiful.
Electrical power in Colville Lake has been provided by diesel generators in a stand-alone micro-grid. It is one of the most expensive diesel generation communities in the Northwest Territories which is why it was chosen for a new power plant concept combining solar power with large scale battery storage and new diesel generators. The goal is to supply the community exclusively with solar power and eliminate diesel generation during the summer. Surplus solar energy will be directed into the batteries, with the battery bank alternating between generation and consumption day and night.
In winter, when the sun rarely shines, the community will continue to be supplied with diesel-powered generators although the operators are hoping to reduce generation time with the new power plant by up to 50 per cent. Shutting down diesel generation for extended periods benefits the community through noise reduction and emissions elimination, cost avoidance, autonomy from total dependence on diesel and greatly improved quality of life. Maintenance requirements are being reduced, and the diesel generator lifespan will be extended, thus reducing operating and replacement costs. In shoulder months solar power can still reduce the need for diesel generation.
To achieve this, we added an 82.5 kW AC solar system, alongside an existing phase-1 50kW solar system which had been installed in 2014. The finished generating system will have a total of 132.5 kW AC solar generation capacity, and over 200 kWhs of battery storage capacity. Monitoring systems allow for remote internet-based monitoring and recording of solar generation data. Our solar system is ground-mounted, using local ballast to avoid disturbing the permafrost because it “floats” on the ground above the permafrost.
Materials were prepared, premachined and pre-assembled in Ontario over the winter, packaged and crated up in custom-made crates for protection during transportation. The winter ice roads are rough and very challenging so sturdy crating is important to avoid transport damage. We safely delivered over 15 tons of solar materials into Colville Lake via winter ice road in February/ March 2015, without any transport damage.
On June 1st we were greeted by a still-frozen lake, snow , frost, and a few very sunny days which brought out a bountiful crop of mosquitoes. Due to the preparation work in our shop over the winter, the on-site work was mainly assembly of pre-machined parts, allowing us to install this project in less than 10 working days. This project was the largest solar installation in NWT in 2015, and to the best of our knowledge the Colville Lake solar system is the largest solar system anywhere north of the Arctic Circle. It is interesting to note that the International Space Station is also powered by an 82 kW solar system, in continuous operation for roughly 12 years.
Our solar system is fixed-angle and maintenance free. Whenever sunshine reaches a module the photovoltaic effect kicks in, and free electrons are generated to provide free and clean electricity to the micro-grid. There are no moving parts and – other than the slow and limited solar cell degradation – no wear and tear. The solar cells are warranted to generate at least 80 per cent of rated output after 25 years. Solar generation is directly linked with sunshine availability. It will still occur with scattered and diffuse light and low light conditions, but to a lesser degree.
Solar cells become more efficient at lower ambient temperatures, so the low air temperatures in the North actually benefit solar generation. Dry air has less water vapour, and allows for more sun energy to penetrate the atmosphere to reach the solar cells. With about 1/3 of the inbound solar energy being absorbed in the atmosphere before reaching the ground, the dryer air in the North allows for noticeably more sun energy to reach the surface. Data for northern communities shows excellent solar energy availability in the summer months. We are monitoring solar systems in NWT, and can compare the data to similar size solar systems in southern Canada. While the solar harvest in NWT in winter is very low to zero, the best solar months in NWT greatly outperform the best solar months in the south. The seasonality in the North is more pronounced, which is what the weather data has been telling us all along. We hope the power plant concept of a combination solar generation/battery bank will be embraced by many other remote communities to reduce and eliminate diesel generation as much as possible. The perfectly quiet and clean, emission- and noise-free operation of a solar system with or without battery storage, offers such an improvement in quality of life for the community, and affords them independence and autonomy, to the degree that sunshine is available and clean energy can be stored. The winter diesel supply truck or barge may not make it, but the sun will always rise with the seasons to provide free and clean energy.
KLAUS DOHRING is president of Green Sun Rising, a Canadian company that develops and supplies solar systems to generate clean electricity and heat.

Mines in the far north also need power, and some are starting to turn to renewables to help fuel their needs. Raglan Mine is part of the Glencore group, one of the largest global diversified natural resource companies. At the northernmost limit of Québec, Canada, Raglan is one of the richest basemetal mines in the world. The Raglan Mine property stretches 70 kilometres from east to west, and encompasses a series of high-grade nickel and copper ore deposits. Jean-François Verret outlines how his company strives to produce nickel safely and in a cost effective manner while showing respect for the environment and their host communities. This article originally appeared in The Circle 03.15.
Our site includes four underground mines, a concentrator, an accommodation complex and administrative buildings. It has all the infrastructures of a small municipality (a source of freshwater supply, fuel tanks, a water treatment plant, a power plant, etc.). A network of all-season roads links our mining site to the Donaldson airport as well as to the Deception Bay warehouses and seaport facilities. The ore extracted from our mines is crushed and processed onsite to produce a nickel-copper concentrate. Raglan Mine strives to be a model in the mining industry in terms of human resource development, equity towards its multicultural workforce and respect for the local communities and the environment. To fulfill this mission, Raglan is based on sustainable development principles.
The facilities of Raglan Mine are neither connected to hydro nor natural gas networks. As a result, we must produce our own electricity from diesel generators. To decrease our greenhouse gas (GHG) emissions and reliance on fossil fuels we have, over the past few years, explored various ways of gradually introducing green energies in our power production portfolio. In 2009, the vision put forward by Raglan Mine on wind energy started to materialize through wind measuring, engineering and environmental impact studies as well as numerous consultation meetings with our host communities and other stakeholders. The four-year process revealed eye-opening results: the average wind speed in the area exceeded our expectations. In December 2013, following successful findings, with our partner TUGLIQ energy – a company that specializes in energy-generation solutions in northern environments – we purchased the wind turbine. This was the official kick-off of the pilot project.
The first step of our pilot project was completed in August 2014 with the erection of a three megawatt wind turbine that is expected to offset the mine’s diesel dependence by 5 per cent, amounting to approximately 2.4 million litres annually. This could decrease our GHG emissions by 7,200 equivalent tonnes of CO2 per year, which is comparable to removing 1,516 vehicles from the road. The second step of this pilot project involves integrating an energy storage system with the energy network to enable maximum energy penetration from the wind turbine. This should be complete this summer and would be the first of its kind in the Canadian Arctic. By twinning the wind turbine with this storage system, we should be able to capture wind power surpluses and save them for times when there is less wind.
We believe our investments in this pilot project will allow us to innovatively decrease our reliance on fossil fuels, maximize our energy efficiency, but more importantly, reduce our carbon footprint and preserve the environment in which we operate. It is our hope that the expertise that we gain related to this pilot project will provide a future benefit to the surrounding Inuit villages.
JEAN-FRANÇOIS VERRET is Director, Projects and Exploration, Raglan Mine, Québec, Canada.